Apparatus for setting equipment in well bores



Q 9 s W 4 7 6 8 M w u w w w e w d d w m K K M \VWQ L m& A m IV Iv V B rM ,..H............ mM w www N B m M MM March 6, 1956 g, BAKER ETALAPPARATUS FOR SETTING EQUIPMENT IN WELL BORES Filed April 27, 1955United States APPARATUS FOR SETTING EQUlPMENT IN WELL BORES ApplicationApril 27, 1953, Serial No. 351,381

12 Claims. (Cl. 166-123) The present invention relates to subsurfacewell tools, and more particularly to tools for setting or operatingother equipment, such as well packers, in well bores.

An object of the present invention is to provide an improved apparatusfor setting or anchoring a well tool, such as a well packer, in a wellcasing or similar well conduit.

Another object of the invention is to provide apparatus for setting oranchoring a well tool in a well conduit by rotating the running-instring to which the apparatus is connected, in which the extent ofrotation required is greatly minimized.

A further object of the invention is to provide apparatus for setting oranchoring a well tool in a well conduit by delivering a hammer-like blowto the well tool.

Still another object of the invention is to provide setting apparatusfor expanding normally retracted segmental slips of a Well tool intoanchoring engagement with a well conduit, the setting apparatus insuringthe transverse alignment of the slips during the outward expansion inorder to secure the well tool in a coaxial position in the well conduit.

Yet a further object of the invention is to provide a spring actuatedsetting apparatus for setting or anchoring a well tool in a well bore,in which the spring is readily energized for operation in the well bore.

This invention possesses many other advantages, and has other objectswhich may be made more clearly apparent from a consideration of severalforms in which it may be embodied. Such forms are shown in the drawingsaccompanying and forming part of the present specification. These formswill now be described in detail, for the purpose of illustrating thegeneral principles of the invention; but it is to be understood thatsuch detailed description is not to be taken in a limiting sense, sincethe scope of the invention is best defined by the appended claims.

Referring to the drawings:

Figure 1 is a longitudinal section, with parts shown in elevation, of awell apparatus disposed within a well casing;

Fig. 2 is an enlarged fragmentary longitudinal section of a portion ofthe well apparatus shown in Fig. 1, with the parts occupying a difierentrelative position;

Fig. 3 is a longitudinal sectional view of a portion of the apparatusdisclosed in Fig. l, with parts shown in another operative position;

Fig. 4 is a cross-section, on a reduced scale, taken along the line 4-4on Fig. 2;

Fig. 5 is an isometric projection of the holding sleeve portion of theapparatus;

Fig. 6 is a view similar to Fig. 1 of another embodiment of theinvention;

Fig. 7 is a fragmentary longitudinal section, on an enlarged scale,disclosing parts of the apparatus in another operative position;

Fig. 8 is a longitudinal section, on an enlarged scale,

atent 9 of a portion of the device shown in Fig. 6, the parts occupyinganother relative position;

Fig. 9 is a cross-section, on a reduced scale, taken along the line 99on Fig. 7;

Fig. 10 is an isometric projection, with parts broken away, of a portionof the actuating mechanism.

Fig. 11 is a longitudinal section, on an enlarged scale, disclosing theparts of the detent device in the setting tool.

The several forms of invention illustrated in the drawings are intendedfor connection to a well packer A, which is to be run into a Well casingB, or similar Well conduit, on a tubular string C, and which is to beanchored in packed-off condition within the well casing by appropriatemanipulation of a setting tool or device D carried by the tubularstring, which actually forms part of the setting device. The well packerA disclosed may be of any suitable construction, the one specificallyshown being of the type described in United States Letters Patent No.2,121,050.

Essentially, the packer A consists of a tubular body 16 to which thesetting tool D is detachably secured. The body has a packing sleeve 11surrounding it, the upper and lower ends or" the latter being suitablysecured to upper and lower conical expanders 12, 13, respectively,attached to the body initially by one or more'screws 14, 15. The outersurface 16 of the upper expander tapers upwardly and inwardly, engagingcorrespondingly tapered upper segmental slips 17 which are secured to itinitially in retracted position by shear screws 18. In similar fashion,the outer surface 19 of the lower expander 13 is tapered inwardly in adownward direction, engaging correspondingly tapered lower segmentalslips 26 secured to the lower expander 13 initially in retractedposition by shear screws 21. The lower end of the body 10 is providedwith a lower abutment 22, in the form of an outwardly directed flange,for engagement with the lower end of the lower segmental slips 20.

A valve housing and guide 23 is secured to the lower end of the body 10.This housing contains a back pressure ball valve 24, preferably buoyantin cement slurry, which is originally prevented from engaging itscompanion valve seat 25 at the lower portion of the body by a retainerarm 26 holding the ball against the housing to one side of the centralpassage 27 through the body. The arm 26 extends upwardly from a tripball seat 28 secured initially in the lower end of the valve housing bya suitable shear screw 29. A ball 30 may be disposed on the trip seat topreclude the downward flow of fluid through the central passage 27 ofthe body and to enable sufiicient pressure to be built up in the body toshear the screw 29, to eject the seat 28 from the valve housing 23, soas to remove the arm 26 from its holding engagement against the ball 30,allowing the latter to shift upwardly into engagement with its companionseat 25.

The shear screws 18 holding the upper slips 17 to the upper expander 12have a lesser shear value than the screws 14 holding the upper expander12 to the body 10. The shear screws 15, 21 securing the lower expander13 to the body 10 and the lower slips 20 to the expander 13 have agreater shear value than the shear screws 14 securing the upper expander12 to the body. The relative strength of the various shear screws areselected in order that the upper slips 17 may first be released fromtheir normally retracted positions through disruption of the slip screws18, to enable the upper slips 17 to expand outwardly against the wellcasing B. Following this action, the shear screws 14 attaching the upperexpander 12 to the body 10 are disrupted, allowing the body 10 to beelevated to move the lower expander toward the upper expander, for thepurpose of foreshortening the packing sleeve 11 and expanding itradially outward into firm sealing engagement with the well casing B. Acontinuation of the upward strain on the body will then disrupt thelower screws 15, 21, shifting the lower slips upwardly along the lowerexpander 13 and radially outward into firm anchoring engagement with thewell casing. Downward movement of the body 19 with respect to theexpanders 12, 13 and the packing sleeve 11 is precluded by theengagement of a split lock or ratchet ring 31 contained in a groove 32in the upper expander 12 with one of a series of circumferential ratchetteeth 33 formed on the exterior of the packer body 1%).

The upper end of the packer body ltl is provided with a left-handthreaded box 34 receiving a companion lefthand threaded pin portion 35of a sub 36, which is, in turn, threadedly secured to the tubularmandrel portion 37 of the tubular string C, the latter extending to thetop of the well bore. The mandrel portion 37 and sub 36 may beconsidered as actually constituting part of the setting device D forshearing the upper slips screws 18 and effecting the downward movementof the upper slips 17 along the upper expander 12 and radially outwardinto anchoring engagement with the wall of the well casing B. Toaccomplish this purpose, a downward force is imposed on the upper slips17, the packer body being prevented from moving downwardly. Since, atthis time, the shear screws 14 for securing the upper expander 12 to thebody are intact, such downward movement of the slips 17 along thecompanion upper expander effects a radial shitting of the upper slipsinto engagement with the wall of the well casing B.

The setting tool D includes the mandrel 3'7 referred to above, the upperend of which may be threaded into a collar 38 threadedly receiving asection of tubing 39 forming a lower portion of the tubular string Cextending to the top of the well bore. Surrounding the mandrel is asetting sleeve 40 whose lower end engages, or is disposed immediatelyadjacent, the upper end of the upper slips 17, the setting sleeve beingthreadedly secured to a setting ring 41 slidable relatively along theexterior of the mandrel 37. The upward position of the setting ring 41and setting sleeve 40 along the mandrel 37 is limited by a suitabledetent device secured to the setting ring 41 and riding in alongitudinal groove 42 in the mandrel. Thus, the detent includes anouter spring seat 43 threaded in the setting ring 41, against which ahelical compression spring 44 bears, the other end of the spring beingreceived within and bearing upon the base portion of a cup-shaped pin 45sliding in the longitudinal mandrel slot 42. The pin engages the upperend 4-6 or wall of the slot,

to prevent further upward movement of the setting ring r 41 and settingsleeve 4% along the mandrel 37. The lower end 47 of the slot is providedwith an outwardly and downwardly tapering wall that will urge the detentpin 45 out of the slot 42 when the ring 41 is moved in a downwarddirection along this tapered wall, for a purpose described hereinafter.

The setting ring 41 and setting sleeve 40 attached thereto are adaptedto be driven downwardly along the mandrel 37 and with respect to thebody ill, for the purpose of shearing the screws 18 attaching the upperslips 17 to the upper expander 12 and shifting the upper slipsdownwardly along the expander and radially outwardly into anchoringengagement with the wall of the well casing B. Such downward shifting iseffected by means of a hammering or impact device. This device includesan impact or inertia member 58, consisting of a lower hammer head 4& towhich inner and outer sleeves 5t 51 are secured in spaced relation, soas to form an annular chamber 52 therebetween. The upper ends of thesesleeves 50, 51 are welded, or otherwise suitably secured, to an upperhead 53, to which a holding sleeve 54- is welded, or otherwise suitablyattached. This upper head 53 also acts as a spring seat for a compressedhelical spring 55 having a substantial compressive force, the upper endof the spring engaging a ring 56 suitably attached to the mandrel. Asdisclosed, this ring may be made in two pieces inserted transverselyinto a peripheral groove 57 in the mandrel 37, and then secured to themandrel as through use of welding material 58.

The compressed spring 55 tends to expand for the purpose of driving theimpact or inertia member 48 downwardly into hammering engagement againstthe upper end of the setting ring 41. Initially, the lower end 49a ofthe hammer head is spaced upwardly away from the setting ring 41, toallow space for the impact member to accelerate sufliciently when thespring 55 is released, so as to impart a substantial hammer-like blow tothe setting ring 41, for the purpose of shearing the slip screws 18 anddriving the slips 17 downwardly along the tapered surface 16 of theupper expander 12. However, the spring 55 is prevented from expanding bya releasable holding device.

This holding device includes a pin 59 attached to the upper two-piecering 56 extending radially outwardly therefrom into an internalcircumferential groove 60 formed at the upper portion of the holdingsleeve 54. The pin 59 engages the upper wall 61 of the groove andthereby secures the holding sleeve 54 and the hammer device 48 in itsinitial upward position, maintaining the heavy spring 55 in itscompressed state. The upper wall 61 of the groove 61) has a verticalslot 62 therein which opens through the upper end of the wall and alsointo the circumferential groove 6d. This vertical slot 62 is wider thanthe diameter of the holding pin 59, so that when the pin is brought intoalignment therewith, the holding sleeve 54 is released to allow thespring 55 to expand and drive the impact device 48 downwardly againstthe setting ring 41. The pin 59 may be placed in alignment with thevertical slot 62 by rotating the mandrel 37, shifting the 59 in thecircumferential groove 60 until it engages a vertical wall 63 inalignment with one side of the vertical slot 62. This vertical wall 63has the purpose of also preventing the pin 59 from becoming aligned withthe vertical slot 62 when the mandrel 37 is rotated in the oppositedirection.

Originally, the pin is disposed against one surface 64 of the verticalwall 63, or almost a complete revolution from the vertical slot 62. Whenin this position, the spring 55 cannot expand. When the mandrel 37 isrotated sufliciently with respect to the holding sleeve 54, which, inthe form of invention illustrated in the drawings, is almost a completerevolution, the pin 59 is placed in alignment with the vertical slot 62,thereby releasing the holding sleeve 54 and allowing the spring 55 toexpand.

In order to effect the necessary relative rotation between the holdingpin 59 and the holding sleeve 54, for the purpose of releasing thelatter, it is necessary to prevent rotation of the holding sleeve. Suchrotation is prevented, in the form of invention disclosed in Figs. 1 to5, inclusive, by a friction drag device 65, which includeslongitudinally spaced upper and lower collars 66, 67 to which aresuitably secured circumferentially spaced outwardly bowed frictionsprings 68 adapted to bear upon the wall of the well casing B. The upperends of the springs 68 are secured to the upper collar 66 by anencompassing retaining ring 69 and screws 70; whereas the lower ends ofthe springs are secured to the lower collar 67 by a lower retaining ring71 and lower screws '72. This lower retaining ring 71 has a dependingskirt 73 which may have an element 74 attached thereto for cooperationwith a lug or finger 75 extending upwardly from the holding sleeve 54.As disclosed, the coupling element 74 is provided by a cap screwthreaded into the skirt 73, the head '76 of the cap screw extendingradially outward from the axis of the mandrel substantially the samedistance as the lug or finger 75.

Until it is desired to effect outward expansion of the upper slips 17into engagement with the Well casing B, it

is preferred to maintain the holding sleeve 54 disconnected ordisengaged from the drag device 65. For this reason, the drag device isallowed to slide upwardly on the mandrel 37 dur'mg the lowering of theapparatus in the well casing, to locate the coupling element 74 abovethe lug 75. Such upward movement of the drag device along the mandrelmay be limited by engagement of the upper retaining ring 69 with theupper coupling collar 38 of the tubular string C. Accordingly, duringlowering of the apparatus in the well casing B, there is no possibilityof the holding sleeve 54 being inadvertently prevented from rotation, sothat inadvertent rotation of the tubular string C can efiect release ofthe pin 59 from the groove 60, which would allow the spring 55 toexpand, and thereby causing premature setting of the well tool in thewell casing. It is only after the desired location in the well casing Bhas been reached at which the well packer A is to be set that the tubingstring C is elevated a slight distance, for the purpose of elevating theholding device in an upward direction until the lug 75 is incircumferential alignment with the coupling element '74. In the eventthat these two parts happen to be in vertical alignment, which mightcause the lug to bump against the lower end of the coupling element, thelug 75 has its upper end pointed, one or the other of the taperedpointed surfaces engaging the pin Sh, sliding the sleeve 54 arcuately toa slight extent, so that the lug comes into full circumferentialalignment with the coupling element 74, as disclosed in Fig. 2.

Thereafter, the entire tubular string C may be rotated almost a fullrevolution, which will rotate the pin 5'9 with the mandrel 37 relativeto the holding sleeve 54, inasmuch as rotation of the latter isprevented by engagement of its ing 75 with the coupling element 74, thecoupling element being prevented from rotating by the frictionalengagement of the springs 63 against the wall of the well casing B. Whenthe pin 59 has been rotated in the circumferential groove 64) until itis in alignment with the vertical slot 62, the pin is no longerefiective to maintain the holding sleeve 54 in an upward direction,releasing the spring 55 and allowing it to expand. Such expansionaccelerates the impacting device 48 and drives it downwardly in a rapidmanner into engagement with the upper end of the setting ring 41, thishammerlike blow being transmitted through the setting sleeve 40 to thetop slips l7, shearing the slip screws 18 and driving the slipsdownwardly over the expander 12 and radially outward into engagementwith the well casing B. After this action has occurred, the tubularstring C may be elevated, to shear the other screws 14, 15, 21,effecting foreshortening and outward expansion of the packing sleeve 11into firm sealing engagement with the wall of the well casing B, andshifting the lower slips upwardly along the lower expander 13 andoutwardly into engagement with the wall of the well casing. Thereafter,pressure may be imparted to the fluid in the tubing string C and packerbody it? to shear the trip ball seat screw 29 and blow it, with the tripball 3% and retaining arm 26, out of the bottom of the valve housing 23,which action will free the back pressure valve member 24 and allow it tomove upwardly into engagement with its companion seat 25.

In the event it is desired to increase the blow struck by the impactingdevice 48 upon the setting ring 41 and setting sleeve 49, the weight ofthe impacting device can be readily increased. As described above, theinner and outer sleeves 5d, 51 of the impact device are spaced from oneanother to provide an annular chamber 52 therebetvveen. The upperportion of the outer sleeve 51 may be provided with a hole or window 73communicating with the chamber. Molten lead '79 may be poured throughthis window 73 into the chamber 52, which will substantially increasethe weight of the impacting device 45 and correspondingly increase thehammer-like blow which is struck by it on the setting ring 41.

The impacting device 48 is easily cocked or disposed in condition toactuate the top slips 17. Prior to the threading of the sub 36 into thepacker body 10, the setting ring 41 and the setting sleeve 40 are moveddownwardly of the mandrel 37, the detent 45 riding along the lowertapered wall 47 of the slot 42 and onto the periphery of the mandrel 37.The setting ring 41 may then be turned a partial revolution, to disalignthe detent 45 and the slot 42. The setting ring 41 can then be movedfreely upwardly along the mandrel 37 until it engages the lower end 49aof the impact hammer head 49. By use of a suitable tool, the settingsleeve 40 and ring 41 can then be urged in an upward direction along themandrel 37, to shift the impact member 48 and the holding sleeve 54upwardly for the purpose of compressing the spring 55. The holdingsleeve 54 is rotated until the pin 5h is aligned with the vertical slot62 and the holding sleeve shifted upwardly to still a further extentuntil the pin 59 is in the circumferential groove 60, whereupon thesleeve 54 and impacting device 48 are rotated almost a completerevolution until the pin 59 is disposed adjacent the wall surface 64, oralmost a complete revolution away from the vertical slot 62. The settingring 41 may then be moved downwardly and its detent 45 allowed to snapback into the longitudinal slot 42 under the influence of the spring 44,the ring 41 then being moved upwardly in the slot 42 until the detentengages the upper wall 46 of the slot, which is substantially normal tothe axis of the mandrel 37. The sub 36 is then threaded into the upperend 34 of the packer body 10, which will dispose the lower end of thesetting sleeve 40 adjacent the upper slips 17.

in the form of apparatus disclosed in Figs. 6 to 10, inclusive,essentially the same operation occurs as was described in connectionwith the embodiment shown in Figs. 1 to 5, inclusive. However, a settingring and setting sleeve intervening between the impacting device and theupper slips is not used. Instead, the impacting device 48:: is caused tooperate directly upon the upper slips 17.

As disclosed, the impacting device 48a includes a sleeve-like memberthat has a lower portion 81 adapted to engage the upper ends of theupper slips 17. This lower portion 81 is initially disposed in spacedrelation to and above the upper slips. The hammering device possesses anintermediate inwardly directed flange portion 82 forming a seat for thelower end of the compressed helical spring SSa, the upper end of thespring engaging a ring or spring seat 83 welded, or otherwise suitablysecured, to the mandrel 37a. The impacting device is initially disposedin the upper position shown in Fig. 6, with the heavy spring 55a held inits highly compressed condition by a holding or retaining device. Asdisclosed, this holding or retaining device includes a pin or cap screw84 disposed in a radial direction and threaded into the sleeve 80 abovethe spring seat 83. The head 85 of the screw engages the upper surfaceof the spring seat 83, to hold the spring 55a compressed.

However, the ring 83 is provided with a vertical slot 86 that is widerthan the diameter of the screw head 85. When this slot 86 is placed inalignment with the head 85, the spring 55a is allowed to expand, torapidly shift the sleeve 80 in a downward direction, for the purpose ofstriking an impact blow upon the upper slips 17, shearing the screws 13and shifting the slips downwardly along the upper expander 12 andradially outward into anchoring engagement with the wall of the wellcasing B.

As described in connection with the other form of the invention, a lugor finger 75a having a pointed end also extends upwardly from thesetting sleeve 80, and this lug is initially disposed in a lowerposition with respect to the coupling element 74 extending from theskirt portion 73 of the drag device 65.

The .parts are assembled in the manner disclosed in Fig. 6, and arelowered in the well casing B to the point the impacting sleeve 89downwardly to dc therewithin at which the well packer A is to be set.During this time, the drag device 65 engages the lower end of thecoupling collar 38, which places the coupling element 7 upwardly awayfrom the lug 75a of the impac sleeve. The holding pin 84 on the sleeveis engaging the upper surface of the spring seat 83 and may be disposedsubstantially diametrically opposite the vertical spring seat slot 8 Atthis time, the lower end 31 of the impact or inertia sleeve is disposedabove and in spaced relation to the upper slips 17.

When it is desired to trip the upper slips F, the tubular string C iselevated, to elevate the entire apparatus, with the exception of thedrag device 65, placing the lug 75a in circumferential alignment withthe coupling ele meat 7 Thereafter, the tubular string C is rotated, theentire apparatus, with the exception of d g or.- vice, rotating untilthe lug 75a engages the c ment 74, which then precludes further to..-impacting sleeve 80. Continued turning string C and the mandrel 37atheir spring seat 83 until its slot 86 is in radial pin Such alignmentremoves the spring 5551, allowing the latter to erect like blow upon theupper slips ll], sh l8 securing the latter to the expander ing the slips17 outwardly into engag casing B. on the tubing string C, mandrel. 3'7.It to complete the anchoring and paclong-o r packer A against thecasing, in the manner described above.

Following the setting of the well packer A in the well casing B, and theblowing out of the trip ball seat l ations can be performed in the wellbore. For example, if cement is to be pumped out of the ell packer A, itmoves down the tubular string C, n drel 3'7 and packer body lit, flowingaround the back pressure ball 24, and out through the lower end of thewell packer. When suilicient cement slurry has been displaced throughthe apparatus, the pressure at the top of tie well bore can be relieved,the back pressure ball moving upwardly into engagement with itscompanion seat 25, to preclude return flow of the cement slurry into thepacker body it? and the tubular string C. Thereafter, the tubular stringC may be rotated to the right, to disconnect the sub 36 from the packerbody at the left-hand threaded connection 34, 35, the tubular string Cand the setting apparatus D then being withdrawn to the top of the wellbore.

It is, accordingly, apparent that setting apparatus for the well packer,or corresponding tool, has been provided in which it is only necessaryto rotate the tubing string C a partial revolution to cifect tripping ofthe upper normally retracted members or slips Rotation of the tubularstring through a plurality of revolutions is not necessary. l'naddition, substantial time i saved in setting the well packer, since thesetting operation can be instituted at any time and w. cut .May, merelyby rotating the tubing string C. lt is not necessary to wait until thetripping ball 3% engages the tripping ball seat 2% for the purpose ofhydraulically setting its well packer, as described in the patent abovereferred to. Such trip ball may take a substantial time in dropping orbeing pumped down through the tubing string C from the top of the wellbore. The impacting device does not operate prematurely, since there isnothing in the well bore tending to prevent its rotation until de. d.The drag device 65 is maintained out of conne the impacting device untilthe well tool is be set in the well casing. in addition, the rapiditywith which 17 causes; all of the slips to be shifted downwardly al theupper expander 12, and radially outward into an- Cir choring engagementwith the well casing, in a transversely aligned position. Accordingly,when the slips l7 engage the well casing, they will have centered thebody 19 of the well packer A in the well casing B, preventing its beingdisposed in a tilted or cooked position. When the tubular string C, itsmandrel 3'7 and the packer body 19 are moved upwardly, for the purposeof completing the setting of the well packer in the well casing, abending moment is not placed upon the 5y ill. which might cause itsdisruption and failure. in many instances, such packer bodies are madeof cast material, such as cast iron or cast magnesium, which do not havegreat strength in bending.

The inventors claim:

1. in well apparatus: a well device havin normally .racted means adaptedto be expanded laterally outward into engagemen with the wall of thewell conduit; a member attached to the well device; means on said memberengageable with said normally retracted means for expanding saidnormally retracted means outwardly, said means on said member comprisinginstrumentalities spaced from and movable toward said normally retractedmeans to impact said normally retracted means, spring means engagingsaid instrumentalities, holding means engaging said spring means andinstrumentalities to hold said spring means in a stressed inoperativecondition and to prevent movement of said instrumentalities relativelyalong said member toward said normally retracted means, and. means forreleasing said holding means to allow said spring means to propelinstrumentalities in a direction to impact said normally retracted meansto expand said normally retracted means outwardly.

2. in well apparatus: a well devi e having normally retracted meansadapted to be expanded laterally out ward into engagement with the wallof the well conduit: a member attached to the well device; means on saidiember engageable with said normally retracted means for expanding saidnormally retracted means outwardly, said means on said member comprisinginstrumentalities spaced from and movable toward said normally retractedmeans to impact said normally retracted means, spring means engagingsaid instrumentalities, holding means engaging said spring means andinstrumentalities to hold said spring means in a stressed inoperativecondition and to prevent movement of said instrumentalities relativelyalong said member toward said normally retracted means, and meansresponsive to manipulation of said member for releasing said holdingmeans to allow said spring means to propel said instrumentalities in adirection to impact said normally retracted means to expand saidnormally retracted means outwardly.

3. In well apparatus: a well device having normally retracted meansadapted to be expanded laterally outward into engagement with the wallof the well conduit; a member attached to the Well device; means on saidmember engageable with said normally retracted means for expanding saidnormally retracted means outwardly, said means on said member comprisinginstrumentalities spaced from and movable toward said normally retractedmeans to impact said normally retracted means, a spring compressedbetween said instrumentalities and a part on said member, first holdingmeans secured to said instrumentalities, second holding means on saidmember releasably engaging said first holding means to hold said springin a compressed inoperative condition and to prevent movement of saidinstrumentalities relatively along said member toward said normallyretracted means, and means for releasing said second holding means fromsaid first holding means in response to rotation of said member to allowsaid spring to expand and propel said instrumentalities in a directionto impact said normally retracted means to expand said normallyretracted means outwardly.

4. In well apparatus: a Well device having normally retracted meansadapted to be expanded laterally outward into engagement with the wallof the well conduit; a member attached to the well device; means on saidmember engageable with said normally retracted means for expanding saidnormally retracted means outwardly, said means on said member comprisinginstrumentalities spaced from and movable toward said normally retractedmeans to impact said normally retracted means, said member beingrotatable relative to said instrumentalities, a spring compressedbetween said instrumentalities and a part on said member, first holdingmeans secured to said instrumentalities, second holding means on saidmember releasably engaging said first holding means to hold said springin a compressed inoperative condition, said second holding means beingreleasable from said first holding means in response to rotation of saidmember to allow said spring to expand and propel said instrumentalitiesin a direction to impact said normally retracted means to expand saidnormally retracted means outwardly, and means engageable with the wellconduit for resisting rotation of said first holding means to enablesaid second holding means to be released from said first holding means.

5. In well apparatus: a well device having normally retracted meansadapted to be expanded laterally outward into engagement with the wallof the well conduit; a member attached to the well device; means on saidmember engageable with said normally retracted means for expanding saidnormally retracted means outwardly, said means on said member comprisinginstrumentalities spaced from and movable toward said normally retractedmeans to impact said normally retracted means, said member beingrotatable relative to said instrumentalities, a spring compressedbetween said instrumentalities and a part on said member, first holdingmeans secured to said instrumentalities, second holding means on saidmember releasably engaging said first holding means to hold said springin a compressed inoperative condition, said second holding means beingreleasable from said first holding means in response to rotation of saidmember to allow said spring to expand and propel said instrumentalitiesin a direction to impact said normally retracted means to expand saidnormally retracted means outwardly, and means engageable with the wellconduit for resisting rotation of said first holding means to enablesaid second holding means to be released from said first holding means,said resisting means and first holding means having coengaging couplingelements adapted to be brought into engaging relation upon relativelongitudinal movement of said first holding means with respect to saidresisting means.

6. In well apparatus: a well device having normally retracted meansadapted to be expanded laterally outward into engagement with the wallof the well conduit; a member attached to the well device; means on saidmember engageable with said normally retracted means for expanding saidnormally retracted means outwardly, said means on said member comprisinginstrumentalities spaced from and movable toward said normally retractedmeans to impact said normally retracted means, said member beingrotatable relative to said instrumentalities, a spring compressedbetween said instrumentalities and a part on said member, first holdingmeans secured to said instrumentalities, second holding means on saidmember releasably engaging said first holding means to hold said springin a compressed inoperative condition, said second holding means beingreleasable from said first holding means in response to rotation of saidmember to allow said spring to expand and propel said instrumentalitiesin a direction to impact said normally retracted means to expand saidnormally retracted means outwardly, and a drag device on said memberfrictionally engageable with said well conduit and operativelyconnectible to said first holding means for resisting rotation of saidfirst holding means to enable said second holding means to be releasedfrom said first holding means.

7. In well apparatus: a well device having normally retracted meansadapted to be expanded laterally outward into engagement with the wallof the well conduit; a member attached to the well device; means on saidmember engageable with said normally retracted means for expanding saidnormally retracted means outwardly, said means on said member comprisinginstrumentalities spaced from and movable toward said normally retractedmeans to impact said normally retracted means, said member beingrotatable relative to said instrumentalities, a spring compressedbetween said instrumentalities and a part on said member, first holdingmeans secured to said instrumentalities, second holding means on saidmember.

releasably engaging said first holding means to hold said spring in acompressed inoperative condition, said second holding means beingreleasable from said first holding means in response to rotation of saidmember to allow said spring to expand and propel said instrumentalitiesin a direction to impact said normally retracted means to expand saidnormally retracted means outwardly, and a drag device on said memberfrictionally engageable with said well conduit and operativelyconnectible to said first holding means for resisting rotation of saidfirst holding means to enable said second holding means to be releasedfrom said first holding means, said drag device being relatively movablelongitudinally of said member into coupling relation with said firstholding means upon longitudinal movement of said member.

8. In well apparatus: a well device having normally retracted meansadapted to be expanded laterally outward into engagement with the wallof a well conduit; a member attached to the well device; means on saidmember engageable with said normally retracted means for expanding saidnormally retracted means outwardly, said means on said member comprisinga sleeve spaced from and movable along said member toward said normallyretracted means to impact said normally retracted means, said memberbeing .rotatable relative to said sleeve, a spring seat on said member,a spring adapted to be compressed between said seat and sleeve,releasable latch means between said member and sleeve to preventlongitudinal movement of said sleeve in one direction along said memberto hold said spring in a compressed inoperative condition, and meansresponsive to rotation of said member within said sleeve for releasingsaid latch means to allow said spring to expand and propel said sleevein a direction to impact said normally retractedmeans to expand saidnormally retracted means outwardly, and means engageable with the wellconduit and operatively connected to said sleeve for resisting rotationof said sleeve.

9. In well apparatus: a well device having normally retracted meansadapted to be expanded laterally outward into engagement with the wallof a well conduit; a member attached to the well device; means on saidmember engageable with said normally retracted means for expanding saidnormally retracted means outwardly, said means on said member comprisinga sleeve spaced from and movable along said member toward said normallyretracted means to impact said normally retracted means, said memberbeing rotatable relative to said sleeve, a spring seat on said member, aspring adapted to be compressed between said seat and sleeve, releasablelatch means between said member and sleeve to preventlongitudinalmovement of said sleeve in on direction along said member to hold saidspring in a compressed inoperative condition, and means responsive torotation of said member within said sleeve for releasing said latchmeans to allow said spring to expand and propel said sleeve in adirection to impact said normally retracted means to expand saidnormally retracted means outwardly, a friction drag device relativelymovable longitudinally along said member, said device being adapted tobe spaced ion: gitudinally from said sleeve and being moved relativelyinto coupling relation with said sleeve upon longitudinal 1 1 movementof said member and sleeve in onedirection to resist rotation of saidsleeve.

10-. In well apparatus: a well device having normally retracted meansadapted to be expanded laterally outward into engagement with the wallof a well conduit; a member attached to the well device; means on saidmember engageable with said normally retracted means for expanding saidnormally retracted means outwardly, said means on said member comprisinga sleeve spaced from and movable along said member toward said normallyretracted means to impact said normally retracted means, said memberbeing rotatable relative to said sleeve, a spring seat on said member, aspring adapted to be compressed between said seat and sleeve, releasablelatch means between said member and sleeve to prevent longitudinalmovement of said sleeve in one direction along said member to hold saidspring in a compressed inoperative condition, means responsive torotation of said member Within said sleeve for releasing said latchmeans to allow said spring to expand and propel said sleeve in adirection to impact said normally retracted means to expand saidnormally retracted means outwardly, means engageable with the wellconduit and operatively connected to said sleeve for resisting rotationof said sleeve, said sleeve having a chamber therein, and weightingmaterial in said chamber.

11. In well apparatus: a well device having normally retracted meansadapted to be expanded laterally outward into engagement with the wallof a well conduit; a member attached to the well device; a settingsleeve slidable on said member and engageable with said normallyretracted means for expanding said normally retracted means outwardly;an impact sleeve initially spaced from and movable along said membertoward said setting sleeve to impact said setting sleeve and normallyretracted means, said member being rotatable relative to said sleeve; aspring adapted to be compressed between said seat and impact sleeve;releasable latch means between said memher and impact sleeve to holdsaid impact sleeve spaced from said setting sleeve and to hold saidspring in a compressed inoperative condition; means for releasing saidlatch means in response to rotation of said member within said impactsleeve to allow said spring to expand and propel said impact sleeve in adirection to impact said setting sleeve and normally retracted means toexpand said normally retracted means outwardly; and means engageablewith the well conduit and operatively connectible to said impact sleevefor resisting rotation of said impact sleeve.

12. In well apparatus: a well device having normally retracted meansadapted to be expanded laterally outward into engagement with the wallof a well conduit; a member attached to the well device; a settingsleeve slidable on said member and engageable with said normallyretracted means for expanding said normally retracted means outwardly;an impact sleeve initially spaced from and movable along said membertoward said setting sleeve to impact said setting sleeve and normallyretracted means, said member being rotatable relative to said sleeve; aspring adapted to be compressed between said seat and impact sleeve;releasable latch means between said mem her and impact sleeve to holdsaid impact sleeve spaced from said setting sleeve and to hold saidspring in a compressed inoperative condition; means for releasing saidlatch means in response to rotation of said member within said impactsleeve to allow said spring to expand and propel said impact sleeve in adirection to impact said setting sleeve and normally retracted means toexpand said normally retracted means outwardly; means engageable withthe well conduit and operatively connectible to said impact sleeve forresisting rotation of said impact sleeve; and means on said settingsleeve engageable with said member to limit movement of said settingsleeve toward said impact sleeve.

Quintrell et a1 Dec. 16, 1941 Taylor et al. Aug. 10, 1943

